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Title: Adaptive Transmission Planning: Implementing a New Paradigm for Managing Economic Risks in Grid Expansion

Abstract

The problem of whether, where, when, and what types of transmission facilities to build in terms of minimizing costs and maximizing net economic benefits has been a challenge for the power industry from the beginning-ever since Thomas Edison debated whether to create longer dc distribution lines (with their high losses) or build new power stations in expanding his urban markets. Today's planning decisions are far more complex, as grids cover the continent and new transmission, generation, and demand-side technologies emerge.

Authors:
; ; ; ; ; ; ; ;
Publication Date:
Research Org.:
National Renewable Energy Lab. (NREL), Golden, CO (United States)
Sponsoring Org.:
USDOE Office of Electricity Delivery and Energy Reliability
OSTI Identifier:
1266693
Report Number(s):
NREL/JA-6A20-66807
Journal ID: ISSN 1540-7977
DOE Contract Number:
AC36-08GO28308
Resource Type:
Journal Article
Resource Relation:
Journal Name: IEEE Power & Energy Magazine; Journal Volume: 14; Journal Issue: 4
Country of Publication:
United States
Language:
English
Subject:
24 POWER TRANSMISSION AND DISTRIBUTION; 29 ENERGY PLANNING, POLICY, AND ECONOMY; demand side management; electricity supply industry; power grids; power stations; power transmission planning

Citation Formats

Hobbs, Benjamin F., Xu, Qingyu, Ho, Jonathan, Donohoo, Pearl, Kasina, Saamrat, Ouyang, Jasmine, Park, Sang Woo, Eto, Joseph, and Satyal, Vijay. Adaptive Transmission Planning: Implementing a New Paradigm for Managing Economic Risks in Grid Expansion. United States: N. p., 2016. Web. doi:10.1109/MPE.2016.2547280.
Hobbs, Benjamin F., Xu, Qingyu, Ho, Jonathan, Donohoo, Pearl, Kasina, Saamrat, Ouyang, Jasmine, Park, Sang Woo, Eto, Joseph, & Satyal, Vijay. Adaptive Transmission Planning: Implementing a New Paradigm for Managing Economic Risks in Grid Expansion. United States. doi:10.1109/MPE.2016.2547280.
Hobbs, Benjamin F., Xu, Qingyu, Ho, Jonathan, Donohoo, Pearl, Kasina, Saamrat, Ouyang, Jasmine, Park, Sang Woo, Eto, Joseph, and Satyal, Vijay. 2016. "Adaptive Transmission Planning: Implementing a New Paradigm for Managing Economic Risks in Grid Expansion". United States. doi:10.1109/MPE.2016.2547280.
@article{osti_1266693,
title = {Adaptive Transmission Planning: Implementing a New Paradigm for Managing Economic Risks in Grid Expansion},
author = {Hobbs, Benjamin F. and Xu, Qingyu and Ho, Jonathan and Donohoo, Pearl and Kasina, Saamrat and Ouyang, Jasmine and Park, Sang Woo and Eto, Joseph and Satyal, Vijay},
abstractNote = {The problem of whether, where, when, and what types of transmission facilities to build in terms of minimizing costs and maximizing net economic benefits has been a challenge for the power industry from the beginning-ever since Thomas Edison debated whether to create longer dc distribution lines (with their high losses) or build new power stations in expanding his urban markets. Today's planning decisions are far more complex, as grids cover the continent and new transmission, generation, and demand-side technologies emerge.},
doi = {10.1109/MPE.2016.2547280},
journal = {IEEE Power & Energy Magazine},
number = 4,
volume = 14,
place = {United States},
year = 2016,
month = 7
}
  • This paper describes the long term transmission expansion planning model CHOPIN. In CHOPIN, the network expansion is formulated as the static optimization problem of minimizing the global annual cost of electricity production, which is obtained as the sum of the annualized network investment cost, the operation cost and the reliability cost. The solution method takes advantage of the natural decomposition between the investment and operation submodels. The investment submodel is solved by a new heuristic procedure that in practice has invariably yielded the optimal plan. At the operation level CHOPIN optimizes over a multiplicity of scenarios which are characterized bymore » the demand, the hydraulicity and the availability of components. The network is represented by any one out of four options: DC load flow (DCLF), transportation model and two hybrid models. Any of these models may consider the ohmic losses. The model is very efficient computationally; this fact was verified on test examples, as well as on the actual transmission expansion planning of the Spanish system.« less
  • A major portion of Manitoba Hydro's generation is located in the North on the Nelson River. The lower Nelson River generation is brought into the load centre in Southern Manitoba through an HVDC transmission system consisting of two bipoles, the first rated at 1680 MW at the rectifier and the second at 2000 MW. This paper presents the methodology used in arriving at the optimum Bipole 3 size using a reliability cost-benefit analysis. The analysis considers the forced outages of the generation and transmission systems using system outage statistics. The generator and valve group maintenance and the reduction in capabilitymore » of thyristor valve groups during the summer season were also incorporated in the analysis. The load model used in the study was based on system data for the period 1980-1984. The criterion used in choosing the Bipole 3 size is to optimize the present worth value of the annual energy curtailment due to the HVDC system forced outages and the incremental installation cost of the transmission as the capacity of Bipole 3 is increased. The optimum Bipole 3 size based on the study is 2200 MW. This value is significantly lower than that based on a pole spare criterion used in the earlier development of the HVDC system. Finally, the need for validation of the outage data in evaluating future HVDC projects and the need for data collection and classification is indicated.« less
  • This paper presents a zero-one implicit enumeration method applied to an integer programming subproblem which has to be solved as part of a more general process of obtaining an optimal solution for a transmission expansion planning problem by hierarchical Benders decomposition. The proposed algorithm has been successfully implemented and tested in a real-life system. The reasons why the implicit enumeration approach is particularly suited for the static expansion planning problem is fully discussed in the paper.
  • This paper presents a simulated annealing approach to the long term transmission expansion planning problem which is a hard, large scale combinatorial problem. The proposed approach has been compared with a more conventional optimization technique based on mathematical decomposition with a zero-one implicit enumeration procedure. Tests have been performed on three different systems. Two smaller systems for which optimal solutions are known have been used to tune the main parameters of the simulated annealing process. The simulated annealing method has then been applied to a larger example system for which no optimal solutions are known: as a result an entiremore » family of interesting solutions have been obtained with costs about 7% less than the best solutions known for that particular example system.« less